Approach to evaluating the CO2 storage capacity in Devonian deep saline aquifers for emissions from oil sands operations in the Athabasca area, Canada

The Province of Alberta is the largest CO2 emitter in Canada, with annual emissions close to 250 Mt, of which about 55 Mt CO2 originate from oil production from oil sands. Geological storage of CO2 has been identified as the major component of the strategy for reducing greenhouse gas emissions from oil sands operations, which are located in the Athabasca area close to the shallow eastern edge of the Alberta basin. Therefore, CO2 storage in deep Devonian saline aquifers, located westward of the oil sands operations, may constitute a solution for storing CO2 from these operations. A regional-scale study of the potential for storing CO2 in deep Devonian saline aquifers in an area covering similar to 126,000 km(2) has been undertaken with the aim of identifying suitable sites for CO2 storage. The Devonian sedimentary succession consists of a succession of stacked sandstone and carbonate saline aquifers separated by intervening shaly and evaporitic aquitards and aquicludes. The approach taken in the study, illustrated in this paper, comprises 11 steps, including: 1) Geological mapping of 29 Devonian formations based on information from more than 34,000 wells; 2) Hydrostratigraphic delineation of the 13 deep saline aquifers identified in this succession; 3) Determination of hydraulic continuity between various aquifers, due to depositional or erosional events; 4) Determination of formation water salinity, which ranges from less than 4000 mg/L (the limit of protected groundwater in Alberta) to close to 440,000 mg/L; 5) Determination of pressures and temperatures in these aquifers, which vary, respectively, between 1 and 30 MPa and between 12 degrees C and 135 degrees C; 6) Determination of the CO2 phase and density at the top of each aquifer, the latter varying between < 25 kg/m(3) where CO2 is in gas phase to >800 kg/m(3) where CO2 is in supercritical state; 7) Determination of well-scale porosity distribution in each aquifer, which varies between 1% and 40%,, based on well logs in 8305 wells and core analyses in 5242 wells; 8) Determination of the areal distribution of CO2 storage capacity in each aquifer, based on aquifer thickness and porosity, and CO2 density; 10) Determination of the regions suitable for CO2 storage in each aquifer based on legal and regulatory constraints and protection of hydrocarbon resources; 10) Determination of permeability distributions in each aquifer, which varies from < 1 mD to > 10 D, based on 214,194 core analyses in 5242 wells and 4318 drill stem tests in 3586 wells; and 11) Identification of target areas for CO2 storage based on local storage capacity and permeability, both of which have to be high at the local scale. Eleven prospective areas in 10 deep saline aquifers, with a cumulative storage capacity of close to 4 Gt CO2, have been identified as a result of this process of evaluation, screening and selection. Crown Copyright (C) 2014 Published by Elsevier Ltd.